Successful Geological Strategy for Setting Intermediate Casing Prior Approaching Kujung Carbonate in Jambaran Field, Cepu Block

2020 ◽  
Author(s):  
R. Fikri
Keyword(s):  
Pore Pressure ◽  
Early Miocene ◽  
Service Company ◽  
Gas Kick ◽  
Reservoir Type ◽  
Ongoing Development ◽  
Conventional Methods ◽  
Oil Rim ◽  
Exploration Well ◽  
Gas Ratio

Jambaran Field was discovered in 2001 by J-1ST1 exploration well. The discovery well encountered steep-flanked carbonate build-up structure (Kujung Fm) that contain thick gas column and thin oil rim. To date six more wells have been drilled to unravel the geometry of the carbonate build up reservoir type. The carbonate build up which is up to 10 km length and 1 km width was deposited during Oligo-Early Miocene and sealed cap by very thick Tuban shale. This stratigraphic configuration has caused several drilling risks. First, there is a huge drop in pore pressure value between Tuban Shale and Kujung Carbonate; of up to 12.6 ppg in Tuban Shale and 8.1-11 ppg in Kujung Carbonate. Second, shale instability commonly happened during drilling Tuban shale. Third, total loss circulation, which can lead to H2S gas kick, potentially happened once penetrating Kujung Carbonate. To reduce those drilling risks, the casing ought to cover as much as Tuban Shale and as close as possible to Kujung Carbonate. During the exploration wells drilling, conventional methods such as; cutting observation, wetness-balance gas ratio, calcimetry, and mud losses have been applied to hunt the casing point as close as possible to Kujung Carbonate. Those conventional methods were successful in several well but also failed in the others. There are many other sophisticated tools developed by Service Company to serve the purpose of set casing, such as resistivity at bit. However, in our ongoing development wells drilling campaign, we utilized the combination of those conventional methods successfully to set 9-5/8” casing point as close as possible without entering Kujung Carbonate.

First MPD Project in Myanmar Successfully Completed on Deepwater Exploration Well

2021 ◽  
Author(s):  
Harpreet Kaur Dalgit Singh ◽  
Bao Ta Quoc ◽  
Benny Benny ◽  
Ching Shearn Ho
Keyword(s):  
Pore Pressure ◽  
Control Device ◽  
Back Pressure ◽  
Deepwater Drilling ◽  
Hole Pressure ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Managed Pressure Drilling ◽  
Pore Pressure Prediction ◽  
Exploration Well

Abstract With the many challenges associated with Deepwater Drilling, Managed Pressure Drilling has proven to be a very useful tool to mitigate many hurdles. Client approached Managed Pressure Drilling technology to drill Myanmar's first MPD well on a Deepwater exploration well. The well was drilled with a Below Tension Ring-Slim Rotating Control Device (BTR-S RCD) and Automated MPD Choke System installed on semi-submersible rig, Noble Clyde Boudreaux (NCB). The paper will detail MPD objectives, application and well challenges, in conjunction with pore pressure prediction to manage the bottom hole pressure to drill to well total depth safely and efficiently. This exploration well was drilled from a water depth of 590m from a Semisubmersible rig required MPD application for its exploratory drilling due to uncertainties of drilling window which contained a sharp pressure ramp, with a history of well bore ballooning there was high potential to encounter gas in the riser. The Deepwater MPD package integrated with the rig system, offered a safer approach to overcome the challenges by enhanced influx monitoring and applying surface back pressure (SBP) to adjust bottom hole pressures as required. Additionally, modified pore pressure hunting method was incorporated to the drilling operation to allow more accurate pore pressure prediction, which was then applied to determine the required SBP in order to maintain the desired minimum overbalance while drilling ahead. The closed loop MPD circulating system allowed to divert returns from the well, through MPD flow spool into MPD distribution manifold and MPD automated choke manifold system to the shakers and rig mud gas separator (MGS). The automated MPD system allows control and adjustments of surface back pressure to control bottom hole pressure. MPD technology was applied with minimal overbalance on drilling and connections while monitoring on background gases. A refined pore pressure hunting method was introduced with manipulation of applied surface back pressure to define this exploration well pore pressure and drilling window. The applied MPD Deepwater technique proved for cost efficiency and rig days to allow two deeper casing setting depths and eliminating requirement to run contingency liners. MPD system and equipment is proving to be a requirement for Deepwater drilling for optimizing drilling efficiency. This paper will also capture detailed lesson learned from the operations as part of continuous learning for improvement on Deepwater MPD drilling.

scholarly journals Modelling of Formation Pore Pressure Inversion during Tight Reservoir Drilling

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-11
Author(s):  
Xiaohui Sun ◽  
Youqiang Liao ◽  
Zhiyuan Wang ◽  
XinXin Zhao ◽  
Baojiang Sun
Keyword(s):  
Pore Pressure ◽  
Early Stage ◽  
Computation Method ◽  
Good Convergence ◽  
Gas Kick ◽  
Tight Reservoir ◽  
Convergence Performance ◽  
Formation Pore Pressure ◽  
Gas Volume ◽  
Robust To Noise

Identifying and controlling a kicking well hinge on quickly obtaining reliable and accurate formation pore pressure. In this study, we derive an analytical model for estimating formation pore pressure when a gas kick occurs during tight reservoir drilling. The model considers the variations in gas volume and pressures in the annulus affected by mutual coupling between the wellbore and formation, as well as bubble migration and expansion in the annulus. Additionally, a numerical computation method that reduces the effect of measurement noise using the Hooke-Jeeves algorithm is proposed. The method is capable of estimating pore pressure during the early stage of a kick in real time, is robust to the inherit noise of the measurements, and can be applied in scenarios when a well shut-in process cannot be performed. The simulation results demonstrate that both kick simulation and formation pore pressure inversion can be conducted via the proposed methodology. The errors of the pore pressure estimating results are less than 2.03% compared to the field data of seven wells. The method is tested and validated to be robust to noise and maintain good convergence performance, thereby providing drilling engineers with a simple and quick way to estimate pore pressure during a kick.

A Practical Technique to Estimate the Formation Thickness of a Kicking Zone

2002 ◽  
Vol 124 (1) ◽  
pp. 1-7
Author(s):  
G. Robello Samuel ◽  
Thomas Engler ◽  
Stefan Miska
Keyword(s):  
Data Analysis ◽  
Pore Pressure ◽  
Limited Information ◽  
Critical Importance ◽  
Mechanical Integrity ◽  
Gas Kick ◽  
Actual Field ◽  
Oil Gas

Characterization of formation while drilling continues to be a challenge to the engineers. When a well kicks while drilling, evaluation of pore pressure and the corresponding kill mud density is of critical importance for the safety of the drilling crew and mechanical integrity of the wellbore. Besides the estimation of these parameters, it will be beneficial to estimate the thickness of the kicking formation prior to drilling. This helps to drill safely and carefully through the potentially active kicking formation. In this paper, it is shown how to calculate the thickness of the kicking zone with the limited information available at the time of an oil/gas kick. A method of data analysis (obtained on a kicking well) to estimate the formation thickness of the kicking zone is presented. Illustrative examples including actual field cases are described and analyzed.

Overcoming Challenges in Pore Pressure Prediction and Wellbore Stability in Brunei Ultra Deepwater Exploration Well Campaign

2016 ◽  
Author(s):  
M Mizuar Omar ◽  
M Faiz Rasli ◽  
M Razali Paimin ◽  
Herry Maulana ◽  
Amitava Ghosh ◽  
...  
Keyword(s):  
Pore Pressure ◽  
Wellbore Stability ◽  
Pore Pressure Prediction ◽  
Exploration Well

Pore Pressure Prediction Based on Seismic Data for Exploration Well Before Drilling

2016 ◽  
Author(s):  
Chen Xin ◽  
Wei Xiaodong ◽  
Wang Hongmei ◽  
Zhao Mingqiu ◽  
Tian Wenyuan ◽  
...  
Keyword(s):  
Pore Pressure ◽  
Seismic Data ◽  
Pore Pressure Prediction ◽  
Exploration Well

Optimizing Pore Pressure Prediction and Wellbore Stability in Drilling Ultra Deepwater Exploration Well

2018 ◽  
Author(s):  
Herry Maulana ◽  
Amitava Ghosh ◽  
M. Razali Paimin ◽  
M Abiabhar Abitalhah
Keyword(s):  
Pore Pressure ◽  
Wellbore Stability ◽  
Pore Pressure Prediction ◽  
Exploration Well

THE RENEWED SEARCH FOR OIL AND GAS IN THE BASS BASIN: RESULTS OF YOLLA-2 AND WHITE IBIS-I

1999 ◽  
Vol 39 (1) ◽  
pp. 248 ◽  
Author(s):  
R.G. Lennon ◽  
R.J. Suttill ◽  
D.A. Guthrie ◽  
A.R. Waldron
Keyword(s):  
Joint Venture ◽  
Oil And Gas ◽  
Oil Accumulation ◽  
Field Development ◽  
Seismic Control ◽  
White Ibis ◽  
Basement High ◽  
Oil Rim ◽  
Coal Measures ◽  
Exploration Well

Boral Energy Resources Ltd and its Joint Venture partners drilled two weUs in the offshore Bass Basin during 1998. Both wells targetted reservoirs in the Upper Cretaceous to Eocene Eastern View Coal Measures (EVCM).Yolla–2, located in Petroleum Licence T/RL1, appraised sandstones within the EVCM, first established gas bearing in the Yolla structure by the 1985 exploration well Yolla–1, drilled by Amoco. The exploration well White Ibis–1, located in adjacent permit T/18P, was a crestal test on a large basement high updip of the 1967 well Bass-3, drilled by Esso.Both wells of the 1998 drilling program encountered gas columns in the objective Paleocene to Lower Eocene section of the EVCM (Intra-EVCM). Liquids-rich gas was recovered from these reservoirs in wireline tests. Formation pressure data suggest a thin oil rim is developed in White Ibis–1. Neither well was tested in cased hole though White Ibis–1 was suspended for potential re-entry. Yolla–1 also encountered a gas and oil accumulation at the top of the Eastern View Coal Measures, but this level was not an objective in Yolla–2.Based on well results and 3D seismic control, a gas resource of between 450–600 BCF OGIP is currently estimated in the Yolla Field. The gas accumulation encountered in White Ibis–1 is estimated at 85 BCF OGIP.The 1998 drilling campaign has provided encour-agement to the T/RL1 and T/18P Joint Ventures to continue the search for both oil and gas in the Bass Basin. Markets for gas are being pursued in both Tasmania and Victoria and engineering studies are being undertaken in parallel to refine parameters for a potential Yolla Field development. The White Ibis Field may provide a candidate as a satellite to such a development. Depending on the outcomes of these studies, further drilling may occur in 1999 to increase confidence in the reserves base in the Yolla Field, and to further evaluate the exploration potential of T/18P.

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